Calcium Carbonate Lost Circulation Material Morphologies For Use In Subterranean Formation Operations

ABSTRACT

Methods including precipitated and mined calcium carbonate lost circulation materials for use in subterranean formation operations. The precipitated calcium carbonate lost circulation materials are formed under a chosen set of precipitation conditions, including in situ in a subterranean formation. The mined calcium carbonate lost circulation materials are obtained in a desired morphological form under naturally occurring mined conditions. The precipitated and mined calcium carbonate lost circulation materials may be needle-shaped aragonite having an aspect ratio of about 1.4 to about 15.

BACKGROUND

The present disclosure relates to subterranean formation operations and,more particularly, to calcium carbonate lost circulation materialmorphologies for use in subterranean formation operations.

Hydrocarbon producing wells (e.g., oil producing wells, gas producingwells, and the like) are created and stimulated using various treatmentfluids introduced into the wells to perform a number of subterraneanformation operations. The general term “treatment fluid,” as usedherein, refers generally to any fluid that may be used in a subterraneanapplication in conjunction with a desired function and/or for a desiredpurpose. The term “treatment fluid” does not imply any particular actionby the fluid or any component thereof.

Hydrocarbon producing wells are first formed by drilling a wellbore intoa subterranean formation, involving circulating a drilling treatmentfluid as the wellbore is bored out using a drill bit. Primary cementingmay then be performed using a cement slurry treatment fluid to enhancethe structural integrity of the wellbore. Stimulation of hydrocarbonproducing wells involves introducing a fracturing treatment fluid,sometimes called a carrier treatment fluid when particulates entrainedtherein. The fracturing treatment fluid is pumped into a portion of asubterranean formation (which may also be referred to herein simply as a“formation”) above a fracture gradient sufficient to break down theformation and create one or more fractures therein. As used herein, theterm “fracture gradient” refers to a pressure (e.g., flow rate)necessary to create or enhance at least one fracture in a subterraneanformation.

Typically, particulate solids are suspended in a portion of one or moretreatment fluids and then deposited into the fractures. The particulatesolids, known as “proppant particulates” or simply “proppant” serve toprevent the fractures from fully closing once the hydraulic pressure isremoved. By keeping the fractures from fully closing, the proppantparticulates form a proppant pack having interstitial spaces that act asconductive paths through which fluids produced from the formation mayflow. As used herein, the term “proppant pack” refers to a collection ofproppant particulates in a fracture, thereby forming a “proppedfracture.”

During any of the aforementioned subterranean formation operations, oradditional subterranean formation operations (e.g., cementingoperations, re-fracturing operations, gravel packing operations,frac-packing operations, acidizing operations, scale dissolution andremoval operations, sand control operations, consolidation operations,and the like), a portion of the treatment fluid used may be lost duringthe operation. This loss may be referred to as “lost circulation,”meaning the reduced or total absence of fluid flow to the surface from awellbore due to loss to the formation itself. This loss may be due, forexample, to undesirable leak-off into natural or created fractures orfissures present in the formation. The loss of the treatment fluids may,among other things, render the treatment fluid less effective orineffective, result in a buildup of any solid materials within theformation (i.e., a “filtercake”) hindering production operations, andthe like.

BRIEF DESCRIPTION OF THE DRAWINGS

The following figures are included to illustrate certain aspects of thepresent disclosure and should not be viewed as exclusive embodiments.The subject matter disclosed is capable of considerable modifications,alterations, combinations, and equivalents in form and function, as willoccur to one having ordinary skill in the art and the benefit of thisdisclosure.

FIG. 1 depicts the needle-shaped precipitated calcium carbonate lostcirculation materials, according to one or more embodiments of thepresent disclosure.

FIG. 2 depicts an illustrative schematic of a drilling assembly in whichtreatment fluids of the present disclosure may be introduced to adownhole location, according to one or more embodiments of the presentdisclosure.

FIG. 3 depicts the effect of manipulating mixing rate precipitationconditions to alter the size of precipitated calcium carbonate lostcirculation materials, according to one or more embodiments of thepresent disclosure.

FIGS. 4A-C depict silica consolidation in the presence of in situprecipitation of calcium carbonate lost circulation materials, accordingto one or more embodiments of the present disclosure.

FIGS. 5A-B depict wellbore strengthening in the presence of in situprecipitation of calcium carbonate lost circulation materials, accordingto one or more embodiments of the present disclosure.

DETAILED DESCRIPTION

The present disclosure relates to subterranean formation operations and,more particularly, to calcium carbonate lost circulation materialmorphologies for use in subterranean formation operations.

Specifically, the present disclosure employs precipitated ornon-precipitated calcium carbonate lost circulation materials, which mayin some instances be precipitated in situ within a subterraneanformation. In other embodiments, the calcium carbonate lost circulationmaterials may be precipitated outside the formation or may be anaturally occurring mined calcium carbonate having desirablemorphological properties for use as a lost circulation material.

One or more illustrative embodiments disclosed herein are presentedbelow. Not all features of an actual implementation are described orshown in this application for the sake of clarity. It is understood thatin the development of an actual embodiment incorporating the embodimentsdisclosed herein, numerous implementation-specific decisions must bemade to achieve the developer's goals, such as compliance withsystem-related, lithology-related, business-related, government-related,and other constraints, which vary by implementation and from time totime. While a developer's efforts might be complex and time-consuming,such efforts would be, nevertheless, a routine undertaking for those ofordinary skill in the art having benefit of this disclosure.

It should be noted that when “about” is provided herein at the beginningof a numerical list, the term modifies each number of the numericallist. In some numerical listings of ranges, some lower limits listed maybe greater than some upper limits listed. One skilled in the art willrecognize that the selected subset will require the selection of anupper limit in excess of the selected lower limit. Unless otherwiseindicated, all numbers expressing quantities of ingredients, propertiessuch as molecular weight, reaction conditions, and so forth used in thepresent specification and associated claims are to be understood asbeing modified in all instances by the term “about.” As used herein, theterm “about” encompasses +/−5% of a numerical value. Accordingly, unlessindicated to the contrary, the numerical parameters set forth in thefollowing specification and attached claims are approximations that mayvary depending upon the desired properties sought to be obtained by theexemplary embodiments described herein. At the very least, and not as anattempt to limit the application of the doctrine of equivalents to thescope of the claim, each numerical parameter should at least beconstrued in light of the number of reported significant digits and byapplying ordinary rounding techniques.

While compositions and methods are described herein in terms of“comprising” various components or steps, the compositions and methodscan also “consist essentially of” or “consist of” the various componentsand steps. When “comprising” is used in a claim, it is open-ended.

As used herein, the term “substantially” means largely, but notnecessarily wholly.

Traditional calcium carbonate lost circulation materials are formed by agrinding process, which offers only a minimal degree of morphologicaltailoring. Grinding processes usually produce only a set particle shape(often substantially spherical) with a broad size range, neither ofwhich may be optimal for use alone as a lost circulation material.Spherical particles, for example, at least when they are alone, may beprone to settling and inducing sag in a treatment fluid or may belimited in their effectiveness based on the size and shape of fracturesor vugs in a formation. In addition, the grinding process may preventfine-tuning of particular shapes and sizes of the calcium carbonate.

Unlike utilizing the traditional method of grinding to form desiredmorphologies of calcium carbonate lost circulation materials, aspreviously discussed, the present disclosure relates to calciumcarbonate lost circulation materials (CCLCMs) that are eitherprecipitated or naturally mined, each having particular morphologicalproperties. CCLCMs formed under a chosen set of precipitation conditionswill be referred to herein as “precipitated calcium carbonate lostcirculation materials” or “PCCLCMs.” The PCCLCMs may be formed in situin a subterranean formation or at a surface location outside of thesubterranean formation, according to the embodiments described herein.CCLCMs obtained in a desired morphological form under naturallyoccurring mined conditions will be referred to herein as “mined calciumcarbonate lost circulation materials” or “MCCLCMs.”

Additionally, the embodiments described herein can reduce costsassociated with purchasing traditional calcium carbonate forsubterranean formation operations, reduce or prevent over usage ofcalcium carbonate (e.g., where it is precipitated and only reactants areused rather than calcium carbonate itself), allow morphologicalmanipulation to ensure effective lost circulation control, enhancecertain qualities of the subterranean formations into which it is placedwhen precipitation occurs in situ, and the like.

Referring first to the PCCLCMs, the PCCLCMs may have significantlydifferent shapes and sizes compared to those produced during grindingprocesses, which has been found to be desirable during the formulationand use of such PCCLCMs in treatment fluids. In addition, by alteringthe conditions under which a precipitation reaction is conducted,differing particle shapes and sizes may be produced, thereby offeringfurther opportunities for tailoring the properties of a treatment fluid.

The precipitation of calcium carbonate occurs instantly when calciumions (Ca²⁺) contact carbonate ions (CO₃ ²⁻). As described in greaterdetail below, these calcium and carbonate ions may be ions in theirnative form (i.e., having a net electric charge) or may be compoundsthat are capable of supplying such ions with the loss or gain of one ormore electrons. The present inventors discovered various precipitationtechniques whereby PCCLCMs may be produced in bulk from readilyavailable materials, where the precipitated particles have a morphologythat may be altered by adjusting the precipitation conditions. As usedherein, the term “morphology” and grammatical variants thereof refers tothe external shape of an object or substance. Depending on the chosenprecipitation conditions, the PCCLCMs may be one of at least three (3)types, each having different morphology: (1) calcite, which issubstantially cubic in shape; (2) vaterite, which is substantiallyspherical in shape; and (3) aragonite, which is needle-shaped. Althougheach shape may be used with some effectiveness, particularly when incombination, the needle-shaped aragonite is especially suitable for useas a CCLCM due to its shape and, thus, its enhanced bridging capacity.As used herein, the term “needle-shaped” refers to an acuate shapehaving an aspect ratio of greater than about 1.4, to an unlimited upperlimit. FIG. 1 shows the shape of the needle-shaped PCCLCMs for use inthe embodiments of the present disclosure. The shape shown in FIG. 1 isequally applicable to the needle-shaped MCCLCMs described herein.

As stated above, the PCCLCMs may be precipitated in situ or at a surfacelocation prior to being introduced into a subterranean formation. Withregard to in situ precipitation, in some embodiments, the presentdisclosure provides a method of introducing a calcium treatment fluidinto a subterranean formation. The calcium treatment fluid comprises anaqueous base fluid and a calcium species. Separately, a carbonatetreatment fluid is introduced into the subterranean formation. Thecarbonate treatment fluid comprises an aqueous base fluid and acarbonate species. Once in the formation together, the calcium speciesand the carbonate species react in situ, thereby forming PCCLCM. As withany treatment fluid described herein, the aqueous base fluid, describedin more detail below, may be the same or different in the calcium andcarbonate treatment fluids, without departing from the scope of thepresent disclosure.

In other embodiments, with regard to in situ precipitation, the presentdisclosure provides a method of introducing a calcium treatment fluidinto a subterranean formation. The calcium treatment fluid comprises anaqueous base fluid and a calcium species. Separately, a supercriticalcarbon dioxide treatment fluid is introduced into the subterraneanformation. Once in the formation together, the calcium species and thesupercritical carbon dioxide react in situ, thereby forming PCCLCM. Thesupercritical carbon dioxide may be used in addition to or apart fromthe carbonate treatment fluid, without departing from the scope of thepresent disclosure. As used herein, the term “supercritical carbondioxide” refers to the fluid state of carbon dioxide where it is held ator above its critical temperature and critical pressure.

The carbonate and/or supercritical carbon dioxide treatment fluids maybe introduced before or after the calcium treatment fluid, withoutdeparting from the scope of the present disclosure. In otherembodiments, the carbonate and/or supercritical carbon dioxide treatmentfluids and the calcium treatment fluid are introduced into thesubterranean formation simultaneously. Whether the calcium treatmentfluid and carbonate and/or supercritical carbon dioxide treatment fluidsare introduced separately at different times or separatelysimultaneously can be used to control the time or location within theformation in which the PCCLCMs are formed. Additionally, pad fluids orother treatment fluids may be included between the introduction of thecalcium treatment fluid and carbonate and/or supercritical carbondioxide treatment fluids to further control such timing and location offorming the PCCLCMs, without departing from the scope of the presentdisclosure. For example, an aqueous plug treatment fluid may beintroduced between the calcium treatment fluid and the carbonate and/orsupercritical carbon dioxide treatment fluids to provide isolationbetween the two fluids. As used herein, the term “aqueous plug treatmentfluid” or simply “aqueous plug” refers to an aqueous fluids comprising agelling agent (e.g., a polysaccharide) that is either linear (i.e.,non-crosslinked) or crosslinked.

The PCCLCMs may be formed in situ using either batch treatment systemsor continuous treatment systems, without departing from the scope of thepresent disclosure. As used herein, the term “batch treatment system”refers to introducing first either the calcium treatment fluid or thecarbonate treatment fluid into a subterranean formation (e.g., to atarget zone therein), followed by the introduction of the othertreatment fluid into the subterranean formation (e.g., to the targetzone therein). As used herein, the term “continuous treatment system”refers to introducing both calcium treatment fluid and carbonatetreatment fluid continuously (simultaneously), although separately, intoa subterranean formation (e.g., to a target zone therein).

The in situ formation of the PCCLCMs can occur in any subterraneanformation type suitable for performing a particular subterraneanformation operation. In some embodiments, the PCCLCMs are formed (i.e.,precipitated) in situ in a sandstone, carbonate, and/or shalesubterranean formation. As used herein, the term “sandstone subterraneanformation” or simply “sandstone formation” refers to a formationcomprising predominately sedimentary rock consisting of sand or quartz.As used herein, the term “shale subterranean formation” or simply “shaleformation” refers to a formation comprising fine-grained, clasticsedimentary rock composed of mud, clay, and silt-sized particles ofother minerals, such as quartz and calcite. As used herein, the term“carbonate subterranean formation” or simply “carbonate formation”refers to a formation comprising carbonate minerals. The formation ofthe PCCLCMs in situ within and in contact with the sandstone, carbonate,and/or shale formation enhances the strength of the thereof bydecreasing the formation's porosity. That is, as the PCCLCMs are formedin situ in the sandstone, carbonate, and/or shale subterraneanformation, the precipitation itself causes the porosity of the formationto decrease, thus enhancing the strength of the thereof, as shown indetail below. In other embodiments, the formation of the PCCLCMs in situwithin and in contact with the sandstone, carbonate, and/or shaleformation enhances the consolidation of loose silica (or sand)particulates present in the therein, as shown in detail below. It willbe appreciated that both the strengthening and consolidation of loosparticulates may occur in the same formation and that such results maybe achieved in formations other than sandstone, carbonate, and shaleformations, without departing from the scope of the present disclosure.

In other embodiments, the PCCLCMs are formed at a surface location andthen placed downhole within a subterranean formation for performing lostcirculation control during one or more subterranean formationoperations. In such instances, the PCCLCMs are formed using a reactionmixture comprising the calcium species and the carbonate species and/orthe supercritical carbon dioxide treatment fluid, as described above.Specifically, the PCCLCM is formed from a reaction mixture comprisingthe calcium species and the carbonate species, or the calcium speciesand the supercritical carbon dioxide treatment fluid, and thepreselected precipitation conditions are selected to achieveparticulates sizes and morphologies of the PCCLCMs. Such preselectedprecipitation conditions include, but are not limited to, theconcentration of the calcium species, the concentration of the carbonatespecies, the mixing rate of the reaction mixture, a temperature of thereaction mixture, the amount of supercritical carbon dioxide, a presenceand amount of any additives described herein, and any combinationthereof. The formed PCCLCMs are then introduced into a lost circulationtreatment fluid comprising a base fluid and introduced into asubterranean formation, again where both a batch treatment system or acontinuous treatment system may be used.

It should be understood that although such preselected precipitationconditions are discussed herein with reference to PCCLCMs formed at asurface location, such conditions may additionally be adjusted toachieve desired sizes and morphologies of PCCLCMs formed in situ,without departing from the scope of the present disclosure. For example,the concentration of both the calcium and carbonate species in theirrespective treatment fluids can be manipulated, the rate or pressure ofthe calcium and carbonate treatment fluids as they are introduced intothe subterranean formation can be manipulated to affect a mixing rate,the temperature of the subterranean formation may be selected based onnatural temperature or otherwise manipulated (e.g., by introducing aheat source or a cooling source), and/or the amount of supercriticalcarbon dioxide introduced into the subterranean formation may bemanipulated, each to affect the size and morphology of the PCCLCMs.Indeed, such manipulation may be preferred when forming PCCLCMs in situto ensure that desired size and morphologies of the PCCLCMs is achieved.

As used herein, the term “PCCLCM” will refer collectively to PCCLCMsformed in situ and at the surface, unless otherwise specified. Thecalcium species for forming the PCCLCMs described herein may be anyspecies capable of providing a calcium ion and suitable for use in asubterranean formation operation. Examples of suitable calcium speciesinclude, but are not limited to, a calcium ion, a calcium soluble salt,and any combination thereof. Examples of suitable calcium soluble saltsinclude, but are not limited to, calcium nitrate, calcium acetate,calcium citrate, calcium gluconate, calcium lactate, calcium bromide,calcium chloride, calcium iodide, calcium nitride, calcium formate, andany combination thereof.

The carbonate species for forming the PCCLCMs described herein may beany species capable of providing a carbonate ion and suitable for use ina subterranean formation operation. Examples of suitable carbonatespecies include, but are not limited to, a carbonate ion, an ammoniumcarbonate ion, a bicarbonate ion, a calcium bicarbonate ion, a Group Icarbonate compound, a Group I bicarbonate compound, and any combinationthereof. The term “Group I” encompasses the elements of hydrogen,lithium, sodium, potassium, rubidium, caesium, and francium.

Referring now to the non-precipitated MCCLCMs, the inventors havediscovered that mined calcium carbonate can be used effectively asCCLCMs when the MCCLCMs are obtained having the particular needle-shapedmorphology described herein. That is, the MCCLCMs are needle-shaped,having an aspect ratio of greater than about 1.4, as they are removedfrom geological formations from the earth. After the MCCLCMs are mined,they are sieved or sized to ensure that they meet the needle-shaped sizespecification described herein for use as a lost circulation material.However, after the MCCLCMs are mined, there is no need to furtherphysically process the MCCLCMs (i.e., no grinding or alteration to theirphysical morphology), thereby reducing costs associated with operatortime, equipment requirements, equipment wearing, and the like.

Whether the PCCLCMs are formed in situ or at the surface, they may beany of spherical, cubic, or needle-shaped in morphology and a mixture ofsuch morphologies may be preferred to achieve lost circulation control.Similarly, such a wide morphological range is possible for MCCLCMs.However, in preferred embodiments, the PCCLCMs and MCCLCMs (collectivelyreferred to simply as “CCLCMs” unless otherwise specified) are at leastpartially needle-shaped, having an aspect ratio of greater than about1.4, to an unlimited upper limit. The needle-shaped CCLCMs mayadvantageously modify the density and rheological properties of atreatment fluid into which it is included. For example, needle-shapedCCLCMs may provide for decreased particle sag, increased viscosity,increased yield strength, and increased fluid loss control when measuredcompared to a treatment fluid comprising an equivalent concentration ofspherical or cubic CCLCMs of like type. As used herein, the term “liketype” refers to CCLCMs having the same predominant chemical composition,but with a differing morphology. For this reason, when used incombination with spherical or cubic CCLCMs, the needle-shaped CCLCMs canaid in increasing their suspension. Additionally, when used in adrilling operation, the needle-shaped CCLCMs will accordingly aid insuspending drill cuttings for removal from the wellbore to the surface.

Moreover, the needle-shaped CCLCMs are able to pack together and act asa bridging agent to control lost circulation. As used herein, the term“bridging agent” refers to a material or substance capable of bridgingacross formation pore throats or fractures to form a filtercake andprevent or reduce loss of treatment fluids. The needle-shaped CCLCMs,due to their unique shape, are able to overlap upon one another and forma woven-like filtercake that may be more effective than like typeCCLCMs. In some embodiments, the aspect ratio of the needle-shapedCCLCMs of the present disclosure is in the range of about 1.4 to about15, encompassing any value and subset therebetween. When the CCLCMs areprecipitated, the aspect ratio is achieved after they are precipitated.For example, the aspect ratio of the needle-shaped CCLCMs may be of fromabout 1.4 to about 3.1, or about 3.1 to about 4.8, or about 4.8 to about6.5, or about 6.5 to about 8.2, or about 8.2 to about 9.9, or about 9.9to about 11.6, or about 11.6 to about 13.3, or about 13.3 to about 15,or about 3.4 to about 13, or about 5.4 to about 11, or about 7.4 toabout 9, encompassing any value and subset therebetween. Each of thesevalues is critical to the embodiments of the present disclosure anddepend on a number of factors including, but not limited to, the type ofsubterranean formation, the size of the area to which the CCLCM isintended to remediate, the combination of other shape or sizes of lostcirculation materials, and the like, and any combination thereof.

The CCLCMs, including the needle-shaped CCLCMs, described herein areshaped and sized such that they are able to provide lost circulationcontrol during a subterranean formation operation. The size of theCCLCMs of the present disclosure may be such that 95% of the CCLCMs havea unit mesh size in the range of about 1 micrometer (μm) to about 100μm, encompassing any value and subset therebetween. As used herein, theterm “unit mesh size” refers to a size of an object (e.g., a CCLCM) thatis able to pass through a square area having each side thereof equal toa specified numerical value. When the CCLCMs are precipitated, the unitmesh size is achieved after they are precipitated. As examples, theCCLCMs may have a unit mesh size of from about 1 μm to about 12.5 μm, orabout 12.5 μm to about 25 μm, or about 25 μm to about 37.5 μm, or about37.5 μm to about 50 μm, or about 50 μm to about 62.5 μm, or about 62.5μm to about 75 μm, or about 75 μm to about 87.5 μm, or about 87.5 μm toabout 100 μm, or about 20 μm to about 80 μm, or about 40 μm to about 60μm, encompassing any value and subset therebetween. Each of these valuesis critical to the embodiments of the present disclosure and depend on anumber of factors including, but not limited to, the type ofsubterranean formation, the size of the area requiring lost circulationcontrol in the formation (e.g., a wide unit mesh size distribution maybe desirable in such circumstances), the presence of non-needle-shapedCCLCMs, and the like, and any combination thereof.

As used herein, the term “treatment fluid” collectively refers to thecalcium treatment fluid, the carbonate treatment fluid, and thesupercritical carbon dioxide treatment fluids of the present disclosure,unless otherwise specifically indicated. The treatment fluids comprisingthe CCLCMs described herein may be used in any subterranean formationoperation requiring lost circulation control, without departing from thescope of the present disclosure. Examples of suitable subterraneanformation operations in which the treatment fluids described herein maybe used include, but are not limited to, a drilling operation, acompletion operation, a hydraulic fracturing operation, a cementingoperation, and any combination thereof.

The treatment fluids described herein comprise a base fluid in additionto the CCLCMs of the present disclosure. The base fluid may be any fluidsuitable for use in a subterranean formation that does not interferewith the ability of the CCLCMs to perform lost circulation control.Examples of suitable base fluids for use in the treatment fluids mayinclude, but are not limited to, an aqueous base fluid, an aqueousmiscible base fluid, an oil base fluid, a water-in-oil emulsion, anoil-in-water emulsion, a viscoelastic surfactant base fluid, and anycombination thereof.

Aqueous base fluids suitable for use in the treatment fluids describedherein may include, but are not limited to, fresh water, saltwater(e.g., water containing one or more salts dissolved therein), brine(e.g., saturated salt water), seawater, produced water (e.g., waterproduced as a byproduct from a subterranean formation during hydrocarbonproduction), waste water (e.g., water that has been adversely affectedin quality by anthropogenic influence) that is untreated or treated, andany combination thereof. Generally, the water may be from any source,provided that it does not contain components that might adversely affectthe stability and/or performance of the treatment fluids. Suitableaqueous-miscible fluids may, in some embodiments, include, but not belimited to, an alcohol (e.g., methanol, ethanol, n-propanol,isopropanol, n-butanol, sec-butanol, isobutanol, and t-butanol), aglycerin, a glycol (e.g., polyglycols, propylene glycol, and ethyleneglycol), a polyglycol amine, a polyol, any derivative thereof, any incombination with a salt (e.g., sodium chloride, calcium chloride,calcium bromide, potassium carbonate, sodium formate, potassium formate,cesium formate, sodium acetate, potassium acetate, calcium acetate,ammonium acetate, ammonium chloride, ammonium bromide, sodium nitrate,potassium nitrate, ammonium nitrate, ammonium sulfate, calcium nitrate,sodium carbonate, and potassium carbonate), any in combination with anaqueous base fluid described above, and any combination thereof.

Suitable oil-based fluids may include, but are not limited to, analkane, an olefin, an aromatic organic compound, a cyclic alkane, aparaffin, a diesel fluid, a mineral oil, a desulfurized hydrogenatedkerosene, and any combination thereof. Suitable water-in-oil emulsions,also known as invert emulsions, may have an oil-to-water ratio of from agreater than about 50:50, to less than about 100:0, encompassing anyvalue and subset therebetween. Suitable oil-in-water emulsions may havea water-to-oil ratio of from a greater than about 50:50, to less thanabout 100:0, encompassing any value and subset therebetween. It shouldbe noted that for water-in-oil and oil-in-water emulsions, any mixtureof the above may be used including the water being and/or comprising anaqueous-miscible fluid.

Viscoelastic surfactant fluids for use as the base fluids describedherein may include, but are not limited to those that are cationic,anionic, or amphoteric in nature. Suitable examples of viscoelasticsurfactant fluids may include, but are not limited to, a methyl estersulfonate, a hydrolyzed keratin, a taurate, an amine oxide, anethoxylated amide, an alkoxylated fatty acid, an alkoxylated alcohol, anethoxylated fatty amine, an ethoxylated alkyl amine, and any combinationthereof.

In various embodiments, the treatment fluids may comprise the CCLCMsdescribed herein, including the needle-shaped CCLCMs alone or incombination, in an amount up to about 70% by volume of the treatmentfluid. When the CCLCMs are precipitated, the amount of PCCLCMs in thetreatment fluid is measured based on post-precipitation. For example,the treatment fluids may comprise about 5% to about 20%, or about 10% toabout 20%, or about 20% to about 40%, or about 25% to about 50%, orabout 40% to about 70%, or about 10% to about 40% by volume of thetreatment fluid, encompassing any value and subset therebetween. Each ofthese values is critical to the embodiments of the present disclosureand may depend on a number of factors including, but not limited to, thesize of the CCLCMs, the type of subterranean formation, the size of thearea to be treated with the CCLCMs, and the like, and any combinationthereof.

In some embodiments, non-calcium carbonate degradable or non-degradablefibers may be included in the treatment fluids to synergisticallyassociate with the CCLCMs to further facilitation formation of afiltercake and enhance lost circulation control. In some embodiments,the fibers, whether degradable or non-degradable, may be preferablyflexible to further facilitate formation of the desired filtercake forlost circulation control. The fibers may have an aspect ratio similar orgreater than the needle-shaped CCLCMs described herein to aid in forminga web-like complex to enhance lost circulation control in combinationwith the CCLCMs. The aspect ratio of the degradable or non-degradablefibers have an aspect ratio of greater than about 5, 10, or 25 to anunlimited upper limit, including greater than about 500, 5000, or 10000,encompassing every value and subset therebetween. The fibers may be thesame unit mesh size as the CCLCMs, as described above, without departingfrom the scope of the present disclosure.

The non-calcium carbonate fibers may be made of any non-calciumcarbonate material suitable for use in a subterranean formationoperation. Examples of such materials include, but are not limited to, aclay, a ceramic, a glass, a zeolite, a polysaccharide (e.g., dextran,cellulose, and the like), a chitin, a chitosan, a silicone, apolyurethane, a protein, an aliphatic polyester, a poly(lactide), apoly(glycolide), a polysulfide, a nitrile rubber, a polybutene, afluorinated thermoplastic elastomer, a poly(c-caprolactone), apoly(hydroxybutyrate), a poly(anhydride), an aliphatic polycarbonate, anaromatic polycarbonate, a poly(orthoester), a poly(amino acid), apoly(ethylene oxide), a polyphosphazene, a polyacrylic, a polyamide, apolyolefin (e.g., polyethylene, polypropylene, polyisobutylene,polystyrene, and the like), and any combination thereof. An example of asuitable commercially available fiber is BAROFIBRE® 0, a cellulosematerial LCM, available from Halliburton Energy Services, Inc. inHouston, Texas.

When included in the treatment fluids described herein, the fibers arepresent in an amount of about 1% to about 30% by weight of the CCLCMs inthe treatment fluid, encompassing any value and subset therebetween. Forexample, in some embodiments, the fibers are present in an amount ofabout 1% to about 6%, or about 6% to about 12%, or about 12% to about18%, or about 18% to about 24%, or about 24% to about 30%, or about 6%to about 24%, or about 12% to about 18% by weight of the CCLCMs in thetreatment fluid, encompassing any value and subset therebetween. Each ofthese values is critical to the embodiments of the present disclosureand depend on a number of factors including, but not limited to, thetype of subterranean formation, the shape and size of the CCLCMs in thetreatment fluid, the size of the area in the formation requiring lostcirculation control, and the like, and any combination thereof.

The treatment fluids described herein may further include an additivefor aiding in performing a particular subterranean formation (e.g.,drilling, hydraulic fracturing, and the like). Any additive suitable foruse in a subterranean formation operation may be used in accordance withthe embodiments described herein provided that it does not interferewith the ability of the CCLCMs (and fibers, if applicable) to providelost circulation control. Examples of suitable additives include, butare not limited to, a salt, a weighting agent (e.g., barite), an inertsolid, a fluid loss control agent, an emulsifier, a dispersion aid, acorrosion inhibitor, an emulsion thinner, an emulsion thickener, agelling agent (e.g., xanthan gum, BARAZAN® D PLUS, a powdered xanthangum, available from Halliburton Energy Services, Inc. in Houston,Texas), a surfactant, a particulate, a proppant, a gravel particulate, atraditional lost circulation material, a foaming agent, a gas, a pHcontrol additive, a breaker, a biocide, a crosslinker, a stabilizer, achelating agent, a scale inhibitor, a gas hydrate inhibitor, a mutualsolvent, an oxidizer, a reducer, a friction reducer, a clay stabilizingagent, and any combination thereof.

The CCLCMs and, if present, fibers forming the lost circulationfiltercakes described herein can be dissolved or degraded to reverse orremove fully or partially the filtercake. In some instances, suchdegradation may be due to formation conditions, such as temperature,pressure, salinity, the presence of produced fluids, and the like. Inother instances, an acid flush fluid may be introduced into thesubterranean formation after the CCLCMs and, if present, fibers haveperformed the desired lost circulation operation to dissolve or degradethe CCLCMs and fibers. In some instances, such an acid flush fluid willadditionally reverse particulate consolidations and/or wellborestrengthening, such as in the case of the sandstone, carbonate, andshale formations, for example.

The acid flush fluid may include an undiluted or diluted acid. Whendiluted, any aqueous base fluid or aqueous-miscible base fluid asdescribed above may be used. Examples of suitable acids for use informing the acid flush fluid include, but are not limited to,hydrochloric acid, nitric acid, formic acid, sulfuric acid, carbonicacid, acetic acid, bromic acid, citric acid, tartartic acid, glutaricacid, folic acid, propionic acid, ascorbic acid, glutamic acid, uricacid, lactic acid, and any combination thereof.

FIG. 2 shows an illustrative schematic of a system that can deliver thetreatment fluids of the present disclosure to a downhole location,according to one or more embodiments. The term “treatment fluid” aspreviously stated encompasses the calcium treatment fluid, the carbonatetreatment fluid, and the supercritical carbon dioxide treatment fluid;it also encompasses the acid flush fluid for the purposes of FIG. 2.

It should be noted that while FIG. 2 generally depicts a land-basedsystem, it is to be recognized that like systems may be operated insubsea locations as well. As depicted in FIG. 2, system 1 may includemixing tank 10, in which the fluids of the embodiments herein may beformulated. The fluids may be conveyed via line 12 to wellhead 14, wherethe fluids enter tubular 16, tubular 16 extending from wellhead 14 intosubterranean formation 18. Upon being ejected from tubular 16, thefluids may subsequently penetrate into subterranean formation 18. Pump20 may be configured to raise the pressure of the fluids to a desireddegree before introduction into tubular 16. It is to be recognized thatsystem 1 is merely exemplary in nature and various additional componentsmay be present that have not necessarily been depicted in FIG. 2 in theinterest of clarity. Non-limiting additional components that may bepresent include, but are not limited to, supply hoppers, valves,condensers, adapters, joints, gauges, sensors, compressors, pressurecontrollers, pressure sensors, flow rate controllers, flow rate sensors,temperature sensors, and the like.

Although not depicted in FIG. 2, the fluid or a portion thereof (e.g.,the broken fluid) may, in some embodiments, flow back to wellhead 14 andexit subterranean formation 18. In some embodiments, the fluid that hasflowed back to wellhead 14 may subsequently be recovered andrecirculated to subterranean formation 18, or otherwise treated for usein a subsequent subterranean operation or for use in another industry.

It is also to be recognized that the disclosed fluids may also directlyor indirectly affect the various downhole equipment and tools that maycome into contact with the fluids during operation. Such equipment andtools may include, but are not limited to, wellbore casing, wellboreliner, completion string, insert strings, drill string, coiled tubing,slickline, wireline, drill pipe, drill collars, mud motors, downholemotors and/or pumps, surface-mounted motors and/or pumps, centralizers,turbolizers, scratchers, floats (e.g., shoes, collars, valves, etc.),logging tools and related telemetry equipment, actuators (e.g.,electromechanical devices, hydromechanical devices, etc.), slidingsleeves, production sleeves, plugs, screens, filters, flow controldevices (e.g., inflow control devices, autonomous inflow controldevices, outflow control devices, etc.), couplings (e.g.,electro-hydraulic wet connect, dry connect, inductive coupler, etc.),control lines (e.g., electrical, fiber optic, hydraulic, etc.),surveillance lines, drill bits and reamers, sensors or distributedsensors, downhole heat exchangers, valves and corresponding actuationdevices, tool seals, packers, cement plugs, bridge plugs, and otherwellbore isolation devices, or components, and the like. Any of thesecomponents may be included in the systems generally described above anddepicted in FIG. 2.

While various embodiments have been shown and described herein,modifications may be made by one skilled in the art without departingfrom the scope of the present disclosure. The embodiments described hereare exemplary only and are not intended to be limiting. Many variations,combinations, and modifications of the embodiments disclosed herein arepossible and are within the scope of the disclosure. Accordingly, thescope of protection is not limited by the description set out above, butis defined by the claims which follow, that scope including allequivalents of the subject matter of the claims.

Embodiments disclosed herein include:

Embodiment A: A method comprising: (a) introducing a calcium treatmentfluid into a subterranean formation, the calcium treatment fluidcomprising a first aqueous base fluid and a calcium species selectedfrom the group consisting of a calcium ion, a calcium soluble salt, andany combination thereof; (b) introducing a carbonate treatment fluidinto the subterranean formation, the carbonate treatment fluidcomprising a third aqueous base fluid and a carbonate species selectedfrom the group consisting of a carbonate ion, an ammonium carbonate ion,a bicarbonate ion, a calcium bicarbonate ion, a Group I carbonatecompound, a Group I bicarbonate compound, and any combination thereof,and/or introducing a supercritical carbon dioxide treatment fluid intothe subterranean formation; (c) reacting the calcium species with one orboth of the carbonate species and/or the supercritical carbon dioxidetreatment fluid in situ in the subterranean formation, thereby formingprecipitated calcium carbonate lost circulation material (PCCLCM)

Embodiment A may have one or more of the following additional elementsin any combination:

Element A1: Wherein the PCCLCM is needle-shaped aragonite having anaspect ratio of about 1.4 to about 15.

Element A2: Wherein greater than about 95% of the PCCLCM have a unitmesh size diameter of about 1 micrometer to about 100 micrometer.

Element A3: Wherein step (a) is performed before step (b), step (b) isperformed before step (a), or step (a) and (b) are performedsimultaneously.

Element A4: Further comprising introducing an aqueous plug treatmentfluid into the subterranean formation between one of: (1) between thecalcium treatment fluid and the carbonate treatment fluid, (2) betweenthe calcium treatment fluid and the supercritical carbon dioxidetreatment fluid, or (3) between the calcium treatment fluid and acombination of the carbonate treatment fluid and the supercriticalcarbon dioxide treatment fluid.

Element A5: Further comprising manipulating a condition selected fromthe group consisting of the concentration of the calcium species, theconcentration of the carbonate species, a flow rate of the calciumtreatment fluid, a flow rate of the carbonate treatment fluid, atemperature of the subterranean formation, a temperature of the calciumtreatment fluid, a temperature of the carbonate treatment fluid, anamount of the supercritical carbon dioxide treatment fluid, a presenceof any additives, an amount of any additives, and any combinationthereof, wherein the manipulation of the condition alters a size and/ora morphology of the PCCLCM.

Element A6: Wherein the subterranean formation is a sandstonesubterranean formation, a carbonate subterranean formation, or a shalesubterranean formation and the PCCLCM further consolidatesunconsolidated particulates therein.

Element A7: Wherein the subterranean formation is a sandstonesubterranean formation, a carbonate subterranean formation, or a shalesubterranean formation and the PCCLCM further decreases the porositythereof.

Element A8: Wherein the calcium soluble salt is selected from the groupconsisting of calcium nitrate, calcium acetate, calcium citrate, calciumgluconate, calcium lactate, calcium bromide, calcium chloride, calciumiodide, calcium nitride, calcium formate, and any combination thereof.

Element A9: Wherein the calcium treatment fluid and the carbonatetreatment fluid and/or the supercritical calcium carbonate treatmentfluid are introduced during an operation selected from the groupconsisting of a drilling operation, a completion operation, a hydraulicfracturing operation, a cementing operation, and any combinationthereof.

Element A10: Further comprising a pump coupled to a tubular extendinginto the subterranean formation, the tubular containing a fluid selectedfrom the group consisting of the calcium treatment fluid, the carbonatetreatment fluid, the supercritical carbon dioxide treatment fluid, andany combination thereof.

By way of non-limiting example, exemplary combinations applicable to Ainclude: A1-A10; A1, A2, and A6; A3 and A9; A2, A5, and A7; A8 and A9;A2, A4, A5, and A6; A7 and A8; and the like.

Embodiment B: A method comprising: forming precipitated calciumcarbonate lost circulation material (PCCLCM) from a reaction mixturecomprising a calcium species and a carbonate species, or a calciumspecies and a supercritical carbon dioxide treatment fluid based onpreselected precipitation conditions, wherein the calcium species isselected from the group consisting of a calcium ion, a calcium solublesalt, and any combination thereof, wherein the carbonate species isselected from the group consisting of a carbonate ion, an ammoniumcarbonate ion, a bicarbonate ion, a calcium bicarbonate ion, a Group Icarbonate compound, a Group I bicarbonate compound, and any combinationthereof, and wherein the preselected precipitation conditions are basedon the manipulation of one or more conditions selected from the groupconsisting of the concentration of the calcium species, theconcentration of the carbonate species, a mixing rate of the reactionmixture, a temperature of the reaction mixture, an amount of thesupercritical carbon dioxide treatment fluid, a presence of anyadditives, an amount of any additives, and any combination thereof; andintroducing a lost circulation treatment fluid into a subterraneanformation, the lost circulation treatment fluid comprising an aqueousbase fluid and the PCCLCM.

Embodiment B may have one or more of the following additional elementsin any combination:

Element B1: Wherein the preselected precipitation conditions areselected such that the PCCLCM are needle-shaped aragonite having anaspect ratio of about 1.4 to about 15.

Element B2: Wherein greater than about 95% of the PCCLCM have a unitmesh size of about 1 micrometer to about 100 micrometer.

Element B3: Wherein the calcium soluble salt is selected from the groupconsisting of calcium nitrate, calcium acetate, calcium citrate, calciumgluconate, calcium lactate, calcium bromide, calcium chloride, calciumiodide, calcium nitride, calcium formate, and any combination thereof.

Element B4: Wherein the lost circulation treatment fluid is introducedduring an operation selected from the group consisting of a drillingoperation, a completion operation, a hydraulic fracturing operation, acementing operation, and any combination thereof.

Element B5: Further comprising a pump coupled to a tubular extendinginto the subterranean formation, the tubular containing the lostcirculation treatment fluid.

By way of non-limiting example, exemplary combinations applicable to Binclude: B1-B5; B1 and B3; B2, B4, and B5; B3 and B4; B2 and B5; B1 andB2; B1 and B4; and the like.

Embodiment C: A method comprising: introducing a lost circulationtreatment fluid into a subterranean formation, the lost circulationtreatment fluid comprising mined calcium carbonate lost circulationmaterial (MCCLCM), wherein the MCCLCM are needle-shaped aragonite havingan aspect ratio of about 1.4 to about 15, and wherein the MCCLCM are notfurther physically processed after they are mined.

Embodiment C may have one or more of the following additional elementsin any combination:

Element C1: Wherein greater than about 95% of the PCCLCM have a unitmesh size of about 1 micrometer to about 100 micrometer.

Element C2: Further comprising a pump coupled to a tubular extendinginto the subterranean formation, the tubular containing the lostcirculation treatment fluid.

Element C3: Wherein the lost circulation treatment fluid is introducedduring an operation selected from the group consisting of a drillingoperation, a completion operation, a hydraulic fracturing operation, acementing operation, and any combination thereof.

By way of non-limiting example, exemplary combinations applicable to Cinclude: C1-C3; C1 and C2; C1 and C3; C2 and C3; and the like.

To facilitate a better understanding of the embodiments of the presentdisclosure, the following examples of preferred or representativeembodiments are given. In no way should the following examples be readto limit, or to define, the scope of the disclosure.

EXAMPLE 1

In this example, adjustment of preselected precipitation conditions forforming PCCLCMs was evaluated to determine the size effect on theformation of the PCCLCMs. A calcium treatment fluid comprising calciumchloride was added into a carbonate treatment fluid comprising 200milliliters (mL) of 0.1 molar (M) Na₂CO₃ carbonate species at threevolumetric rates. The calcium treatment fluid was added 0.833 millimolesper minute (mmol/min), 1.25 mmol/min, and 2.5 mmol/min. As shown in FIG.3, relatively larger PCCLCMs were formed at the lowest rate of 0.833mmol/min rate and relatively smaller PCCLCMs were formed at the highestrate of 2.5 mmol/min, and PCCLCMs sized therebetween were formed at themiddle rate of 1.25 mmol/min.

EXAMPLE 2

In this example, the MCCLCMs of the present disclosure were compared totraditional spherical calcium carbonate particulates, BARACARB®available from Halliburton Energy Services, Inc. in Houston, Texas. Twotreatment fluids (TF1 and TF2) were prepared according to Table 1 below.Each of the components is either in pounds per barrel (ppb) or mL. Thereare 42 gallons (equivalent to 3.7854 liters) in a barrel. The symbol“--” indicates that the particular component was not included in thetreatment fluid.

Component TF1 TF2 Water (base fluid) (ppb) 331 331 BARAZAN ® D PLUS 1.51.5 (gelling agent) (ppb) Barite (weighting agent) (ppb) 97 97 325 Meshneedle-shaped 10 — aragonite MCCLCM (ppb) MCCLCM (ppb, needle-shaped) 10— BAROFIBRE ® O (fiber) (ppb) 10 10 BARACARB ® 50 (ppb) — 10 BARACARB ®400 (ppb) — 10

A fluid loss test was performed on each of TF1 and TF2. The fluid losstest was performed by use of a particle plugging apparatus. The test wasperformed on a 190 μm aloxite disc at room temperature and 500 poundsper square inch differential pressure. The test fluid was one barrel of10 pounds per gallon viscosified water-based mud. The spurt loss andtotal fluid loss are shown in Table 2 for each treatment fluid. Asshown, TF1 comprising the needle-shaped aragonite MCCLCMs resulted in afluid loss of almost half of that of TF2 comprising traditionalspherical calcium carbonate. If used in a drilling operation, forexample, it is further believed that the needle-shaped MCCLCMs of thepresent disclosure would significantly reduce the amount of lostcirculation due to drill solids and other particulates aiding infiltercake production.

EXAMPLE 3

In this example, the ability of the PCCLCMs formed in situ toconsolidate silica particulates in a subterranean formation wasevaluated. Unconsolidated silica particulates, as seen in FIG. 4A, weretreated with 170 millimoles (mmol) Na₂CO₃ containing 5 weight percent(wt %) of silica sand and an equaled-molar addition of CaCl₂ solution at150 mL/hr. FIG. 4B depicts the unconsolidated silica particulates with acalcium carbonate “crust” formed from precipitation of the PCCLCMs incontact with the unconsolidated silica particulates. FIG. 4C shows theconsolidation effect of the unconsolidated silica particulates aftercontact as the PCCLCMs were precipitated in situ, as apparent from thesize difference between the initial unconsolidated silica particulates(FIG. 4A) and the subsequent consolidated silica particulates (FIG. 4C).

EXAMPLE 4

In this example, the ability of the PCCLCMs formed in situ to strengthena subterranean formation was evaluated. A sandstone core sample wassubmerged in a carbonate treatment fluid of 0.5 M Na₂CO₃ solution for 12hours, and then submerged in a calcium treatment fluid of 0.5 M CaCl₂solution. The submerged core sample was placed in an oven at 150° F.(65.56° C.) overnight. As shown in FIG. 5A, formation of the PCCLCMsoccurred outside of the core sample. The interior of the core sample wasaccessed and, as shown in FIG. 5B, it was further observed thatformation of the PCCLCMs also occurred within the core sample. A visibledecrease in porosity was observed on both the exterior and interior ofthe core sample due to the in situ formation of the PCCLCMs, enhancingthe strength of the core sample itself

Therefore, the present disclosure is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent disclosure may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. Furthermore, no limitations areintended to the details of construction or design herein shown, otherthan as described in the claims below. It is therefore evident that theparticular illustrative embodiments disclosed above may be altered,combined, or modified and all such variations are considered within thescope and spirit of the present disclosure. The disclosureillustratively disclosed herein suitably may be practiced in the absenceof any element that is not specifically disclosed herein and/or anyoptional element disclosed herein. While compositions and methods aredescribed in terms of “comprising,” “containing,” or “including” variouscomponents or steps, the compositions and methods can also “consistessentially of” or “consist of” the various components and steps. Allnumbers and ranges disclosed above may vary by some amount. Whenever anumerical range with a lower limit and an upper limit is disclosed, anynumber and any included range falling within the range are specificallydisclosed. In particular, every range of values (of the form, “fromabout a to about b,” or, equivalently, “from approximately a to b,” or,equivalently, “from approximately a-b”) disclosed herein is to beunderstood to set forth every number and range encompassed within thebroader range of values. Also, the terms in the claims have their plain,ordinary meaning unless otherwise explicitly and clearly defined by thepatentee. Moreover, the indefinite articles “a” or “an,” as used in theclaims, are defined herein to mean one or more than one of the elementthat it introduces.

What is claimed is:
 1. A method comprising: forming a precipitatedcalcium carbonate lost circulation material (PCCLCM) from a reactionmixture comprising a calcium species and a carbonate species, or acalcium species and a supercritical carbon dioxide treatment fluid basedon preselected precipitation conditions; and introducing a lostcirculation treatment fluid into a subterranean formation, the lostcirculation treatment fluid comprising an aqueous base fluid and thePCCLCM.
 2. The method of claim 1, wherein the precipitated calciumcarbonate lost circulation material is formed at a surface location. 3.The method of claim 1, wherein the calcium species is selected from thegroup consisting of a calcium ion, a calcium soluble salt, and anycombination thereof.
 4. The method of claim 1, wherein the carbonatespecies is selected from the group consisting of a carbonate ion, anammonium carbonate ion, a bicarbonate ion, a calcium bicarbonate ion, aGroup I carbonate compound, a Group I bicarbonate compound, and anycombination thereof.
 5. The method of claim 1, wherein the preselectedprecipitation conditions are based on a manipulation of one or moreconditions selected from the group consisting of a concentration of thecalcium species, a concentration of the carbonate species, a mixing rateof the reaction mixture, a temperature of the reaction mixture, anamount of the supercritical carbon dioxide treatment fluid, a presenceof any additives, an amount of any additives, and any combinationthereof.
 6. The method of claim 1, wherein the preselected precipitationconditions are selected such that the PCCLCM are needle-shaped aragonitehaving an aspect ratio of about 1.4 to about
 15. 7. The method of claim1, wherein greater than about 95% of the PCCLCM have a unit mesh size ofabout 1 micrometer to about 100 micrometer.
 8. The method of claim 3,wherein the calcium soluble salt is selected from the group consistingof calcium nitrate, calcium acetate, calcium citrate, calcium gluconate,calcium lactate, calcium bromide, calcium chloride, calcium iodide,calcium nitride, calcium formate, and any combination thereof.
 9. Themethod of claim 1, wherein the lost circulation treatment fluid isintroduced during an operation selected from the group consisting of adrilling operation, a completion operation, a hydraulic fracturingoperation, a cementing operation, and any combination thereof.
 10. Themethod of claim 1, wherein the aqueous base fluid comprises offreshwater, saltwater, brine, seawater, produced water, wastewater, andany combination thereof.
 11. A method comprising: forming a precipitatedcalcium carbonate lost circulation material (PCCLCM) from a reactionmixture comprising a calcium species and a carbonate species, or acalcium species and a supercritical carbon dioxide treatment fluid basedon preselected precipitation conditions, wherein the calcium species isselected from the group consisting of a calcium ion, a calcium solublesalt, and any combination thereof, wherein the carbonate species isselected from the group consisting of a carbonate ion, an ammoniumcarbonate ion, a bicarbonate ion, a calcium bicarbonate ion, a Group Icarbonate compound, a Group I bicarbonate compound, and any combinationthereof, and wherein the preselected precipitation conditions are basedon a manipulation of one or more conditions selected from the groupconsisting of aconcentration of the calcium species, a concentration ofthe carbonate species, a mixing rate of the reaction mixture, atemperature of the reaction mixture, an amount of the supercriticalcarbon dioxide treatment fluid, a presence of any additives, an amountof any additives, and any combination thereof, and introducing a lostcirculation treatment fluid into a subterranean formation, the lostcirculation treatment fluid comprising an aqueous base fluid and thePCCLCM.
 12. The method of claim 11, wherein the precipitated calciumcarbonate lost circulation material is formed at a surface location. 13.The method of claim 11, wherein greater than about 95% of the PCCLCMhave a unit mesh size of about 1 micrometer to about 100 micrometer. 14.The method of claim 11, wherein the preselected precipitation conditionsare selected such that the PCCLCM are needle-shaped aragonite having anaspect ratio of about 1.4 to about
 15. 15. The method of claim 11,wherein the calcium soluble salt is selected from the group consistingof calcium nitrate, calcium acetate, calcium citrate, calcium gluconate,calcium lactate, calcium bromide, calcium chloride, calcium iodide,calcium nitride, calcium formate, and any combination thereof.
 16. Themethod of claim 11, wherein the lost circulation treatment fluid isintroduced during an operation selected from the group consisting of adrilling operation, a completion operation, a hydraulic fracturingoperation, a cementing operation, and any combination thereof.
 17. Themethod of claim 11, further comprising a pump coupled to a tubularextending into the subterranean formation, the tubular containing thelost circulation treatment fluid.
 18. The method of claim 11, whereinthe aqueous base fluid comprises of freshwater, saltwater, brine,seawater, produced water, wastewater, and any combination thereof.
 19. Amethod comprising: forming a precipitated calcium carbonate lostcirculation material (PCCLCM) from a reaction mixture comprising acalcium species and a carbonate species, or a calcium species and asupercritical carbon dioxide treatment fluid based on preselectedprecipitation conditions, wherein the calcium species is selected fromthe group consisting of a calcium ion, a calcium soluble salt, and anycombination thereof, wherein the carbonate species is selected from thegroup consisting of a carbonate ion, an ammonium carbonate ion, abicarbonate ion, a calcium bicarbonate ion, a Group I carbonatecompound, a Group I bicarbonate compound, and any combination thereof,and wherein the preselected precipitation conditions are based on amanipulation of one or more conditions selected from the groupconsisting of a concentration of the calcium species, a concentration ofthe carbonate species, a mixing rate of the reaction mixture, atemperature of the reaction mixture, an amount of the supercriticalcarbon dioxide treatment fluid, a presence of any additives, an amountof any additives, and any combination thereof, and wherein thepreselected precipitation conditions are selected such that the PCCLCMare needle-shaped aragonite having an aspect ratio of about 1.4 to about15; and introducing a lost circulation treatment fluid into asubterranean formation, the lost circulation treatment fluid comprisingan aqueous base fluid and the PCCLCM.
 20. The method of claim 19,wherein the lost circulation treatment fluid is introduced during anoperation selected from the group consisting of a drilling operation, acompletion operation, a hydraulic fracturing operation, a cementingoperation, and any combination thereof.